CN112300829B - Deep dehydration and desalination method for crude oil containing surfactant for oil displacement - Google Patents
Deep dehydration and desalination method for crude oil containing surfactant for oil displacement Download PDFInfo
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- 239000003921 oil Substances 0.000 title claims abstract description 237
- 239000010779 crude oil Substances 0.000 title claims abstract description 173
- 230000018044 dehydration Effects 0.000 title claims abstract description 128
- 238000006297 dehydration reaction Methods 0.000 title claims abstract description 128
- 239000004094 surface-active agent Substances 0.000 title claims abstract description 112
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 98
- 238000000034 method Methods 0.000 title claims abstract description 39
- 238000010612 desalination reaction Methods 0.000 title claims abstract description 36
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 249
- 229920000642 polymer Polymers 0.000 claims abstract description 110
- 239000000839 emulsion Substances 0.000 claims abstract description 67
- 238000004062 sedimentation Methods 0.000 claims abstract description 19
- 238000004581 coalescence Methods 0.000 claims abstract description 13
- 239000007788 liquid Substances 0.000 claims description 43
- 239000000203 mixture Substances 0.000 claims description 17
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 14
- 238000010438 heat treatment Methods 0.000 claims description 14
- 229920000570 polyether Polymers 0.000 claims description 14
- 239000000126 substance Substances 0.000 claims description 9
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 8
- -1 polyoxypropylene Polymers 0.000 claims description 8
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 4
- 229920003171 Poly (ethylene oxide) Polymers 0.000 claims description 4
- 239000005011 phenolic resin Substances 0.000 claims description 4
- 229920001568 phenolic resin Polymers 0.000 claims description 4
- 229920001451 polypropylene glycol Polymers 0.000 claims description 4
- 208000005156 Dehydration Diseases 0.000 abstract description 113
- 150000003839 salts Chemical class 0.000 abstract description 52
- 230000008569 process Effects 0.000 abstract description 15
- 239000002245 particle Substances 0.000 abstract description 4
- 239000011521 glass Substances 0.000 description 17
- 238000012360 testing method Methods 0.000 description 17
- 239000004033 plastic Substances 0.000 description 16
- 229920003023 plastic Polymers 0.000 description 16
- 238000012546 transfer Methods 0.000 description 9
- 238000011033 desalting Methods 0.000 description 7
- 238000005070 sampling Methods 0.000 description 7
- 235000009827 Prunus armeniaca Nutrition 0.000 description 6
- 244000018633 Prunus armeniaca Species 0.000 description 6
- 238000005516 engineering process Methods 0.000 description 6
- 238000011084 recovery Methods 0.000 description 6
- 230000005684 electric field Effects 0.000 description 5
- 230000033558 biomineral tissue development Effects 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 230000005686 electrostatic field Effects 0.000 description 4
- 238000011156 evaluation Methods 0.000 description 4
- 238000005260 corrosion Methods 0.000 description 3
- 230000007797 corrosion Effects 0.000 description 3
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical group [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical group [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 239000003054 catalyst Substances 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- 230000006872 improvement Effects 0.000 description 2
- 239000002736 nonionic surfactant Substances 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 229920002401 polyacrylamide Polymers 0.000 description 2
- 238000007670 refining Methods 0.000 description 2
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 2
- 230000002776 aggregation Effects 0.000 description 1
- 238000004220 aggregation Methods 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- 239000002585 base Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 239000003814 drug Substances 0.000 description 1
- 229940079593 drug Drugs 0.000 description 1
- 238000004945 emulsification Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 231100000572 poisoning Toxicity 0.000 description 1
- 230000000607 poisoning effect Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000003908 quality control method Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 229910000029 sodium carbonate Inorganic materials 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G53/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes
- C10G53/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G33/00—Dewatering or demulsification of hydrocarbon oils
- C10G33/04—Dewatering or demulsification of hydrocarbon oils with chemical means
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1033—Oil well production fluids
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The invention provides a deep dehydration and desalination method for a mine field of crude oil containing a surfactant for oil displacement, which is used for solving the problem that the water content and/or salt content of part of crude oil with high surfactant content for oil displacement exceeds the standard after being treated by a free water removal-thermochemical sedimentation process and a free water removal-electrochemical dehydration process. The method comprises the specific steps of doping crude oil containing the surfactant for oil displacement, of which the water content and/or the salt content exceed the standard after thermochemical settling or electrochemical dehydration, into W/O type crude oil emulsion with low water content obtained by water displacement or polymer displacement, adding a demulsifier, and then performing thermochemical settling or electrostatic coalescence to realize deep dehydration and desalination of the crude oil containing the surfactant for oil displacement. The method realizes deep dehydration and desalination of crude oil containing the surfactant for oil displacement by carrying out secondary dehydration treatment and utilizing coalescence between low-salinity water drops with larger particle sizes in W/O type crude oil emulsion produced by water displacement and polymer flooding and fine water drops in crude oil containing the surfactant for oil displacement.
Description
Technical Field
The invention relates to the technical field of oil extraction in oil fields, in particular to a method for dewatering and desalting a mine field containing crude oil with a surfactant for oil displacement, which realizes chemical flooding such as alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding, surfactant-polymer flooding and the like.
Background
As a practical technology capable of greatly improving the crude oil recovery ratio, chemical flooding technologies such as alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding, surfactant-polymer flooding and the like are developed in recent years for industrial application or large-scale field application tests, the recovery ratio improvement range can reach more than 10%, and the method plays an important role in improving the crude oil recovery ratio and increasing the crude oil yield.
While greatly improving the recovery ratio of crude oil, alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding and surfactant-polymer flooding also bring new problems to crude oil dehydration. The surfactant injected in chemical flooding such as alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding, surfactant-polymer flooding and the like can greatly reduce the tension of an oil-water interface in produced liquid, so that the particle size of part of water drops in W/O type crude oil emulsion or W/O/W type crude oil emulsion produced by an oil well is very small and can reach below 1 mu m. The water drops are too small in particle size and difficult to remove through gravity sedimentation, so that crude oil emulsions produced by alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding and surfactant-polymer flooding with high surfactant content are subjected to conventional oil-gas separation, free water removal, thermochemical sedimentation and electric dehydration (electrostatic coalescence), and then contain a part of fine water drops with the diameter of less than 5 mu m, so that the water content and the salt content cannot reach the quality control indexes of the commercial crude oil, corrosion in an oil pipeline is aggravated, corrosion and catalyst poisoning accidents of crude oil processing equipment of an oil refinery due to the fact that the crude oil salt content exceeds the standard are caused, and a rectifying tower is flooded due to the fact that the water content in the crude oil is too high. The main methods for solving the problems of dehydration and desalination of crude oil in oil field and mining field at present comprise free water removal-thermochemical sedimentation, free water removal-electric dehydration (electrostatic coalescence) and free water removal-electric dehydration and desalination processes, wherein the first two processes are mainly used for the condition of low mineralization degree of produced water, and under the condition, the salt content can meet the requirement as long as the dehydrated crude oil can meet the water content control index; the third treatment process is mainly used in the case of high salinity of produced water, and in this case, in order to improve the crude oil desalting effect, the crude oil needs to be mixed with washing brine with low salinity in the electric desalting process. Due to the fact that chemical-flooding produced liquid oil-water interfacial tension of ternary combination flooding, salt-surfactant-polymer flooding, surfactant-polymer flooding and the like with high surfactant content is low, the oil-water emulsification degree is high, a large amount of fine water drops with the diameter smaller than 5 microns, which are difficult to remove through gravity settling and electrostatic coalescence, are contained in W/O type crude oil emulsion obtained after the produced liquid removes free water, and the crude oil water content after long-time thermochemical settling and electric dehydration processes is higher than the control index of the commodity crude oil water content. Meanwhile, the mineralization degree of produced water of the ASP flooding and the salt-surfactant-polymer flooding is far higher than that of produced water of the water flooding and the polymer flooding, and the salt content of the produced water is overproof under the condition that the content of crude oil and water is overproof, so that the corrosion of a downstream oil pipeline and oil refining equipment is aggravated, and a catalyst of an oil refining device is poisoned. The free water removal-electric dehydration desalination process is obviously better than the free water removal-thermochemical sedimentation process and the free water removal-electric dehydration process in dehydration and desalination effects, but the treatment process is relatively complex and high in investment and operation cost, so that the free water removal-electric dehydration desalination process is only used for the condition of high mineralization degree of the produced water. In order to improve the dehydration effect of crude oil produced by alkali-surfactant-polymer flooding, a method for mixing and dehydrating ASP flooding produced liquid and water flooding and/or polymer flooding produced liquid is adopted in part of oil field dehydration stations, the overall dehydration effect of crude oil produced by ASP flooding, water flooding and polymer flooding treated by the dehydration stations can be obviously improved under the conditions that the content of the surfactant in the ASP flooding produced liquid is low and the proportion of the surfactant in the mixed produced liquid is low, but under the conditions that the content of the surfactant in the ASP flooding produced liquid is high and the proportion of the surfactant in the mixed produced liquid is high, the mixed dehydration mode can often cause that an electric dehydrator can not establish an effective dehydration electric field, and the overall dehydration of crude oil produced by ASP flooding, water flooding and polymer flooding does not reach the standard.
Disclosure of Invention
The invention provides a deep dehydration and desalination method for a mine site for crude oil containing a surfactant for oil displacement, aiming at overcoming the problem that the water content and/or salt content of part of crude oil with high surfactant content for oil displacement in the background technology exceeds the standard after being treated by a free water removal-thermochemical sedimentation process and a free water removal-electrochemical dehydration process. The method for deep dehydration and desalination of the crude oil containing the surfactant for oil displacement in the mine field comprises the steps of mixing the crude oil containing the surfactant for oil displacement, which does not reach the water content and/or the salt content after thermochemical sedimentation or electrical dehydration, into a W/O type crude oil emulsion obtained by water flooding or polymer flooding for secondary dehydration, and realizing deep dehydration and desalination of the crude oil containing the surfactant for oil displacement by utilizing coalescence between water drops with large particle sizes in the W/O type crude oil emulsion obtained by water flooding and polymer flooding and fine water drops in the crude oil containing the surfactant for oil displacement.
The invention can solve the problems by the following technical scheme: a deep dehydration and desalination method for a mine field containing oil displacement surfactant crude oil comprises the following steps:
s1, mixing the crude oil containing the surfactant for oil displacement after thermochemical settling or electrochemical dehydration into the W/O type crude oil emulsion with low water content produced by water displacement or polymer displacement through a pipeline;
s2, adding a demulsifier into the oil displacement surfactant-containing crude oil subjected to thermal chemical sedimentation or electrochemical dehydration in S1 or/and the water-flooding or polymer flooding produced low-water-content W/O type crude oil emulsion to form a blend liquid added with the demulsifier;
and S3, performing thermochemical settling or electrostatic coalescence on the blend liquid added with the demulsifier in the S2 to realize deep dehydration and desalination of the crude oil containing the surfactant for oil displacement.
The crude oil containing the surfactant for oil displacement is low-water-content crude oil obtained by thermochemical settling or electrochemical dehydration of chemical displacement produced liquids such as alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding, surfactant-polymer flooding and the like.
The demulsifier is a block polyether type nonionic macromolecular surfactant; the block polyether type nonionic high molecular surfactant is polyoxypropylene polyoxyethylene phenolic resin ether (AR-36); the demulsifier is added into the W/O type crude oil emulsion which is produced by water flooding or polymer flooding and is mixed with crude oil containing a surfactant for oil displacement.
The content of emulsified water in each kg of crude oil containing the surfactant for oil displacement is 8.7-46 mL; the content of the surfactant for oil displacement of emulsified water in each liter of crude oil containing the surfactant for oil displacement is 151 mg-522 mg; the water content of the W/O type crude oil emulsion produced by each kg of water flooding or polymer flooding is 58 mL-279 mL; the oil content of the surfactant crude oil containing oil displacement, which is mixed into each liter of W/O type crude oil emulsion produced by water flooding or polymer flooding, is 200 mL-1000 mL; the dosage of the block polyether type nonionic high molecular surfactant in the W/O type crude oil emulsion produced by water flooding or polymer flooding, which is doped with crude oil containing a surfactant for oil displacement, per liter is 50-150 mg.
In the S3, dehydration heating furnace/heat exchanger, electric dehydrator or dehydration tank is used for deep dehydration and desalination of crude oil containing surfactant for oil displacement.
Compared with the background technology, the invention has the following beneficial effects: the method can realize deep dehydration and desalination of the mine site of the crude oil containing the surfactant for oil displacement by adding the crude oil containing the surfactant for oil displacement, which has the water content and/or the salt content exceeding the standard after thermochemical settling or electrochemical dehydration, into the W/O type crude oil emulsion with low water content obtained by water displacement or polymer displacement, adding the demulsifier, and performing thermochemical settling or electrostatic coalescence, thereby solving the problem that the water content and/or the salt content exceeds the standard after part of the crude oil with high content of the surfactant for oil displacement is treated by a free water removal-thermochemical settling process and a free water removal-electrochemical dehydration process; compared with the treatment mode of directly mixing and dehydrating the ternary combination flooding produced liquid and the water flooding or polymer flooding produced liquid, the method has the advantages that the water content of the crude oil containing the surfactant for oil displacement and with the water content and/or the salt content exceeding the standard after thermochemical settling or electrochemical dehydration is low, the proportion of fine water drops in the crude oil is small, the thermochemical settling dehydration and the electric dehydration of the W/O type crude oil emulsion obtained by water displacement and polymer displacement are less interfered, the coalescence efficiency of large water drops in the W/O type crude oil emulsion with the low water content and the residual fine water drops in the crude oil containing the surfactant for oil displacement and obtained by water displacement and polymer displacement can be obviously improved, the surfactant content and the mineralization degree of separated produced water in the thermochemical settling and electrochemical dehydration of the mixed oil are reduced, and the dehydration and desalination efficiency is improved.
Description of the drawings:
FIG. 1 is a schematic diagram of a process flow of dehydration and desalination of crude oil containing a surfactant for oil displacement.
In the figure: 1-oil displacement surfactant-containing crude oil subjected to thermochemical settling or electrochemical dehydration; 2-W/O type crude oil emulsion without oil displacement surfactant; 3-a demulsifier dosing device; 4-a dehydration heating device; 5-a dewatering device; 6-dehydrating the crude oil; 7-dewatering device drainage.
Detailed Description
The present invention will be further described with reference to the following drawings and examples, but the present invention is not limited to the following examples.
A deep dehydration and desalination method for a mine field containing oil displacement surfactant crude oil comprises the following steps:
s1, mixing the crude oil containing the surfactant for oil displacement after thermochemical settling or electrochemical dehydration into the W/O type crude oil emulsion with low water content produced by water displacement or polymer displacement through a pipeline; the crude oil containing the surfactant for oil displacement is low-water-content crude oil obtained by thermochemical settling or electrochemical dehydration of chemical displacement produced liquids such as alkali-surfactant-polymer flooding (ternary combination flooding), salt-surfactant-polymer flooding, surfactant-polymer flooding and the like.
S2, adding a demulsifier into the oil displacement surfactant-containing crude oil subjected to thermal chemical sedimentation or electrochemical dehydration in S1 or/and the water-flooding or polymer flooding produced low-water-content W/O type crude oil emulsion to form a blend liquid added with the demulsifier; the demulsifier is a block polyether type nonionic macromolecular surfactant; the block polyether type nonionic high molecular surfactant is polyoxypropylene polyoxyethylene phenolic resin ether (AR-36); the demulsifier is added into the W/O type crude oil emulsion which is produced by water flooding or polymer flooding and is mixed with crude oil containing a surfactant for oil displacement.
S3, performing thermochemical settling or electrostatic coalescence on the blend liquid added with the demulsifier in the S2 to realize deep dehydration and desalination of the crude oil containing the surfactant for oil displacement; in the S3, dehydration heating furnace/heat exchanger, electric dehydrator or dehydration tank is used for deep dehydration and desalination of crude oil containing surfactant for oil displacement.
The content of emulsified water in each kg of crude oil containing the surfactant for oil displacement is 8.7-46 mL; the content of the surfactant for oil displacement of emulsified water in each liter of crude oil containing the surfactant for oil displacement is 151-522 mg; the water content of the W/O type crude oil emulsion produced by each kg of water flooding or polymer flooding is 58 mL-279 mL; the oil content of the surfactant crude oil containing oil displacement, which is mixed into each liter of W/O type crude oil emulsion produced by water flooding or polymer flooding, is 200 mL-1000 mL; the dosage of the block polyether type nonionic high molecular surfactant in the W/O type crude oil emulsion produced by water flooding or polymer flooding, which is doped with crude oil containing a surfactant for oil displacement, per liter is 50-150 mg.
The invention relates to a deep dehydration and desalination method for a mine field containing oil displacement surfactant crude oil, which is applied to the North I-2 block and the Xingwu block of a Daqing oil field.
In the north I-2 row block of Daqing oil field, the base-surfactant-polymer flooding (ternary combination flooding) technology is adopted to improve the crude oil recovery rate, the injected base is sodium carbonate, the surfactant is petroleum sulfonate, and the polymer is partially hydrolyzed polyacrylamide. The water content of the W/O type crude oil emulsion separated from the block ternary combination flooding produced liquid is 9.8 percent, the pH of the water phase is 8.7, the content of the surfactant is 554mg/L, and the content of the polymer is 598 mg/L. After 24-hour standing and settling and 60-minute indoor desktop electric dehydration and desalination device treatment, the W/O type crude oil emulsion has residual water content of 0.87% and 0.92% respectively, which are far greater than the control index of the content of 0.5% of commercial crude oil water; and simultaneously, the residual salt content of the oil sample after standing sedimentation and electric dehydration treatment is respectively 129mg/L and 135mg/L, and the residual salt content is larger than the commercial crude oil salt content control index of 34 mg/L.
In the Daqing oil field, the salt-surfactant-polymer flooding technology is adopted to improve the crude oil recovery rate, the injected salt is sodium chloride, the surfactant is petroleum sulfonate, and the polymer is partially hydrolyzed polyacrylamide. W/O type crude oil emulsion (water content 23.0%, pH of water phase 8.5, surfactant content 151mg/L, polymer content 520mg/L) separated from oil well output liquid in the block. The residual water content and the salt content of the W/O type crude oil emulsion after standing and settling treatment for 36 hours at the temperature of 60 ℃ are respectively 0.91 percent and 88.4mg/L, and the content of the commercial crude oil water is respectively greater than 0.5 percent and 34 mg/L.
Example 1
Adding 1000mL of W/O type crude oil emulsion (with the water content of 9.8 percent, the pH of the water phase of 8.7, the surfactant content of 554mg/L and the polymer content of 598mg/L) separated from the ternary combination flooding produced liquid of the northern I-2 row block of the Daqing oil field into a Schott bottle with the capacity of 1000mL, and standing in a water bath with the water temperature of 60 ℃ for 24 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; sequentially adding 50ml of low-water emulsified oil (the water-phase polymer content is 395mg/L and the water content is 27.9%) separated from oil transportation outside a polymeric flooding oil transfer water station of the Daqing oilfield and 50ml of oil sample which is subjected to standing and sedimentation for 24h at 60 ℃ above the low-water emulsified oil into 2 glass prescription bottles with the capacity of 160 ml; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, and placing the formula bottle on a TH-10 type oscillator to oscillate for 2min at the frequency of 300 r/min; respectively pouring the oil samples in the two formula bottles into 2 glass dehydration electrode bottles with the capacity of 80ml to reach the scale of 80 ml; after a dehydration electrode assembly is inserted into a dehydration electrode bottle, the dehydration electrode assembly is placed in a DPY-ZET type desk type electric desalting evaluation instrument to be subjected to electric dehydration treatment for 60min under the conditions of 55 ℃ and 100% power; taking the dehydration electrode assembly out of the glass dehydration electrode bottle, extracting 40ml of oil sample from the upper part of the electrode bottle by using a 10ml plastic graduated pipette, and transferring the oil sample into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then sampled to test the water content and salt content as shown in Table 1. Standing and settling W/O type crude oil emulsion separated from the ternary combination flooding produced liquid in the North I-2 row of blocks of the Daqing oil field at the temperature of 24h and 60 ℃ to obtain low water-containing oil with the water content and the salt content of 0.87 percent and 128mg/L respectively, and polymer flooding produced W/O type crude oil emulsion with the water content of 27.9 percent according to the volume ratio of 1: 1 the residual water content and salt content of the resulting mixed oil sample after adding 100mg/L demulsifier and dehydrating by 60min 55 ℃ AC electrostatic field (electric field strength at 60min 4872v/cm) were 0.29% and 16.5mg/L, respectively.
TABLE 1
Example 2
Adding 1000mL of W/O type crude oil emulsion (with the water content of 9.8 percent, the pH of the water phase of 8.7, the surfactant content of 554mg/L and the polymer content of 598mg/L) separated from the ternary combination flooding produced liquid of the northern I-2 row block of the Daqing oil field into a Schott bottle with the capacity of 1000mL, and standing in a water bath with the water temperature of 60 ℃ for 24 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; sequentially adding 50ml of oil sample in the 500ml Schott bottle and 50ml of low-water-content emulsified oil (the water-phase polymer content is 395mg/L, the water content is 15.1%) separated from the oil output of the Daqing oilfield poly-drive oil transfer water discharging station and 50ml of oil sample which is subjected to standing and sedimentation for 24h at 60 ℃ above into 2 glass prescription bottles with the capacity of 160 ml; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, and placing the formula bottle on a TH-10 type oscillator to oscillate for 2min at the frequency of 300 r/min; respectively pouring the oil samples in the two formula bottles into 2 glass dehydration electrode bottles with the capacity of 80ml to reach the scale of 80 ml; after a dehydration electrode assembly is inserted into a dehydration electrode bottle, the dehydration electrode assembly is placed in a DPY-ZET type desk type electric desalting evaluation instrument to be subjected to electric dehydration treatment for 60min under the conditions of 55 ℃ and 100% power; taking the dehydration electrode assembly out of the glass dehydration electrode bottle, extracting 40ml of oil sample from the upper part of the electrode bottle by using a 10ml plastic graduated pipette, and transferring the oil sample into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 2. Standing and settling W/O type crude oil emulsion separated from the ternary combination flooding produced liquid in the North I-2 row of blocks of the Daqing oil field at the temperature of 24h and 60 ℃ to obtain low water-containing oil with the water content and the salt content of 0.87 percent and 128mg/L respectively, and polymer flooding produced W/O type crude oil emulsion with the water content of 15.1 percent according to the volume ratio of 1: 1 the residual water content and the salt content of the mixed oil sample obtained by mixing are respectively 0.27 percent and 17.4mg/L after 100mg/L of demulsifier is added and dehydrated by an alternating current electrostatic field at the temperature of 60min and 55 ℃ (the electric field intensity at 60min is 4838 v/cm).
TABLE 2
Example 3
Adding 17ml of oil (the water content is 4.6%, the pH of a water phase is 9.0, the surfactant content is 427mg/L, the polymer content is 598mg/L, and the salt content is 159mg/L) from a ternary combination flooding electric dehydrator of a certain dehydration station of the Daqing oilfield and 83ml of low-water-content emulsified oil (the water phase polymer content is 395mg/L, and the water content is 27.9%) separated from the oil output of a polydrive oil transfer drainage station of the Daqing oilfield in sequence into 2 glass prescription bottles with 160ml of capacity; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, and placing the formula bottle on a TH-10 type oscillator to oscillate for 2min at the frequency of 300 r/min; respectively pouring the oil samples in the two formula bottles into 2 glass dehydration electrode bottles with the capacity of 80ml to reach the scale of 80 ml; after a dehydration electrode assembly is inserted into a dehydration electrode bottle, the dehydration electrode assembly is placed in a DPY-ZET type desk type electric desalting evaluation instrument to be subjected to electric dehydration treatment for 60min under the conditions of 55 ℃ and 100% power; taking the dehydration electrode assembly out of the glass dehydration electrode bottle, extracting 40ml of oil sample from the upper part of the electrode bottle by using a 10ml plastic graduated pipette, and transferring the oil sample into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 3. The oil discharged from the ternary combination flooding electric dehydrator of a certain dehydrating station of Daqing oil field with the water content and the salt content of 4.6 percent and 159mg/L respectively and the W/O type crude oil emulsion with the water content of 27.9 percent produced by polymer flooding according to the volume ratio of 1: 5 mixing the obtained mixed oil sample, adding 100mg/L demulsifier, dehydrating with 60min 55 deg.C alternating current electrostatic field (electric field strength of 4989v/cm at 60 min), and making the residual water content and salt content be 0.22% and 20.5mg/L, respectively.
TABLE 3
Example 4
Adding 1000mL of W/O type crude oil emulsion (with the water content of 9.8 percent, the pH of the water phase of 8.7, the surfactant content of 554mg/L and the polymer content of 598mg/L) separated from the ternary combination flooding produced liquid of the northern I-2 row block of the Daqing oil field into a Schott bottle with the capacity of 1000mL, and standing in a water bath with the water temperature of 60 ℃ for 24 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; respectively and sequentially adding 50ml of low-water emulsified oil (the water-phase polymer content is 395mg/L and the water content is 5.8%) separated from the oil output outside a polymeric flooding oil transfer water station of the Daqing oilfield and 50ml of oil sample which is subjected to standing and sedimentation for 24 hours at 60 ℃ above the low-water emulsified oil into 2 glass formula bottles with the capacity of 160 ml; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, placing the formula bottle on a TH-10 type oscillator, oscillating for 2min at the frequency of 300r/min, and then placing the formula bottle back in the water bath for standing for 48 h; respectively extracting 50ml of oil samples from the upper parts of 2 formula bottles by using a 10ml plastic graduated pipette, and transferring the oil samples into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 4. Standing and settling W/O type crude oil emulsion separated from the ternary combination flooding produced liquid in the North I-2 row of blocks of the Daqing oil field at the temperature of 24h and 60 ℃ to obtain low water-containing oil with the water content and the salt content of 0.87 percent and 128mg/L respectively, and polymer flooding produced W/O type crude oil emulsion with the water content of 5.8 percent according to the volume ratio of 1: 1 mixing the obtained mixed oil sample, and adding 50mg/L demulsifier, and standing and settling at 48h and 55 ℃ to obtain a mixed oil sample with residual water content of 0.07 percent and salt content of 20.8mg/L respectively.
TABLE 4
Example 5
Adding 1000mL of W/O type crude oil emulsion (with the water content of 9.8 percent, the pH of the water phase of 8.7, the surfactant content of 554mg/L and the polymer content of 598mg/L) separated from the ternary combination flooding produced liquid of the northern I-2 row block of the Daqing oil field into a Schott bottle with the capacity of 1000mL, and standing in a water bath with the water temperature of 60 ℃ for 24 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; respectively and sequentially adding 50ml of low-water emulsified oil (the water-phase polymer content is 395mg/L and the water content is 5.8%) separated from the oil output outside a polymeric flooding oil transfer water station of the Daqing oilfield and 50ml of oil sample which is subjected to standing and sedimentation for 24 hours at 60 ℃ above the low-water emulsified oil into 2 glass formula bottles with the capacity of 160 ml; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, placing the formula bottle on a TH-10 type oscillator, oscillating for 2min at the frequency of 300r/min, and then placing the formula bottle back in the water bath for standing for 24 h; respectively extracting 50ml of oil samples from the upper parts of 2 formula bottles by using a 10ml plastic graduated pipette, and transferring the oil samples into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 5. Standing and settling W/O type crude oil emulsion separated from the ternary combination flooding produced liquid in the North I-2 row of blocks of the Daqing oil field at the temperature of 24h and 60 ℃ to obtain low water-containing oil with the water content and the salt content of 0.87 percent and 128mg/L respectively, and polymer flooding produced W/O type crude oil emulsion with the water content of 5.8 percent according to the volume ratio of 1: 1 mixing the obtained mixed oil sample, and adding 100mg/L demulsifier, and standing and settling at 48h and 55 ℃ to obtain a mixed oil sample with residual water content and salt content of 0.19% and 20.5mg/L respectively.
TABLE 5
Example 6
Adding 1000mL of W/O type crude oil emulsion (with the water content of 9.8 percent, the pH of the water phase of 8.7, the surfactant content of 554mg/L and the polymer content of 598mg/L) separated from the ternary combination flooding produced liquid of the northern I-2 row block of the Daqing oil field into a Schott bottle with the capacity of 1000mL, and standing in a water bath with the water temperature of 60 ℃ for 24 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; respectively and sequentially adding 50ml of low-water emulsified oil (the content of a water-phase polymer is 395mg/L and the water content is 27.9%) separated from the oil output outside a polymeric driving oil transfer water station of a Daqing oilfield and 50ml of oil sample which is subjected to standing and sedimentation for 24h at 60 ℃ above the low-water emulsified oil into 2 glass formula bottles with the capacity of 160 ml; placing the formula bottle in a water bath with the water temperature of 60 ℃ for preheating for 10min, adding a demulsifier, placing the formula bottle on a TH-10 type oscillator, oscillating for 2min at the frequency of 300r/min, and then placing the formula bottle back in the water bath for standing for 48 h; respectively extracting 50ml of oil samples from the upper parts of 2 formula bottles by using a 10ml plastic graduated pipette, and transferring the oil samples into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 6. Standing and settling W/O type crude oil emulsion separated from the ternary combination flooding produced liquid of the North I-2 row block of Daqing oil field at the temperature of 60 ℃ for 24h to obtain low water-containing oil with the water content of 0.87 percent and polymer with the water content of 27.9 percent, and flooding the obtained W/O type crude oil emulsion according to the volume ratio of 1: 1 mixing the obtained mixed oil sample, and adding 150mg/L demulsifier, standing and settling for 48h at 60 ℃, wherein the residual water content and the salt content are respectively 0.21 percent and 10.5 mg/L.
TABLE 6
Example 7
Adding 17ml of oil (the water content is 4.6%, the pH of a water phase is 9.0, the surfactant content is 427mg/L, the polymer content is 598mg/L, and the salt content is 159mg/L) from a ternary combination flooding electric dehydrator of a certain dehydration station of the Daqing oilfield and 83ml of low-water-content emulsified oil (the water phase polymer content is 395mg/L, and the water content is 27.9%) separated from the oil output of a polydrive oil transfer drainage station of the Daqing oilfield in sequence into 2 glass prescription bottles with 160ml of capacity; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, placing the formula bottle on a TH-10 type oscillator, oscillating for 2min at the frequency of 300r/min, and then placing the formula bottle back in the water bath for standing for 48 h; respectively extracting 50ml of oil samples from the upper parts of 2 formula bottles by using a 10ml plastic graduated pipette, and transferring the oil samples into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 7. The oil discharged from the ternary combination flooding electric dehydrator of a certain dehydrating station of Daqing oil field with the water content and the salt content of 4.6 percent and 159mg/L respectively and the W/O type crude oil emulsion with the water content of 27.9 percent produced by polymer flooding according to the volume ratio of 1: 5 mixing the obtained mixed oil sample, and adding 200mg/L demulsifier, standing and settling at 24h and 55 ℃, wherein the residual water content and the salt content are respectively 0.32 percent and 18.2 mg/L.
TABLE 7
Example 8
Adding 1000mL of W/O type crude oil emulsion (the water content is 23.0 percent, the pH of the water phase is 8.5, the surfactant content is 151mg/L and the polymer content is 520mg/L) separated from a certain salt-surfactant-polymer flooding well output liquid of the Daqing oilfield apricot five blocks into a Schott bottle with the volume of 1000mL, and placing the obtained mixture in a water bath with the water temperature of 60 ℃ for standing for 36 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; 71ml of low-water emulsified oil (the content of a water-phase polymer is 395mg/L, the water content is 27.9%) separated from oil transportation outside a polymeric driving oil transfer water station of the Daqing oilfield and 29ml of oil sample which is settled by standing for 36h at 60 ℃ are respectively and sequentially added into 2 glass formula bottles with the capacity of 160 ml; placing the formula bottle in a water bath with the water temperature of 55 ℃ for preheating for 10min, adding a demulsifier, placing the formula bottle on a TH-10 type oscillator, oscillating for 2min at the frequency of 300r/min, and then placing the formula bottle back in the water bath for standing for 36 h; respectively extracting 50ml of oil samples from the upper parts of 2 formula bottles by using a 10ml plastic graduated pipette, and transferring the oil samples into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 8. The water content and the salt content of low water-containing oil which are respectively 0.91 percent and 88.4mg/L and the water content of polymer flooding W/O type crude oil emulsion which is separated from certain salt-surfactant-polymer flooding well output liquid of the Daqing oilfield apricot five blocks are subjected to standing and sedimentation for 36h at 60 ℃ and the W/O type crude oil emulsion which is separated from the polymer flooding well output liquid of the Daqing oilfield apricot five blocks is prepared by the following steps: 5 mixing the obtained mixed oil sample, and adding 150mg/L demulsifier, and standing and settling at 36h and 55 ℃ to obtain a mixed oil sample with residual water content of 0.23% and salt content of 19.1mg/L respectively.
TABLE 8
Example 9
Adding 1000mL of W/O type crude oil emulsion (the water content is 23.0 percent, the pH of the water phase is 8.5, the surfactant content is 151mg/L and the polymer content is 520mg/L) separated from a certain salt-surfactant-polymer flooding well output liquid of the Daqing oilfield apricot five blocks into a Schott bottle with the volume of 1000mL, and placing the obtained mixture in a water bath with the water temperature of 60 ℃ for standing for 36 hours; using a 10ml plastic graduated pipette to extract 500ml of oil layer from the upper part of the Schott bottle, and transferring the oil layer into the Schott bottle with the capacity of 500 ml; turning a 500ml Schott bottle containing the oil sample upside down for 10 times to uniformly mix the oil sample, and sampling to test the water content and the salt content of the oil sample; 71ml of low-water emulsified oil (the content of a water-phase polymer is 395mg/L, the water content is 27.9%) separated from oil transportation outside a polymeric driving oil transfer water station of the Daqing oilfield and 29ml of oil sample which is settled by standing for 36h at 60 ℃ are respectively and sequentially added into 2 glass formula bottles with the capacity of 160 ml; placing the formula bottle in water bath with water temperature of 60 deg.C, preheating for 10min, adding demulsifier, placing on TH-10 type oscillator, and oscillating at frequency of 300r/min for 2 min; respectively pouring the oil samples in the two formula bottles into 2 glass dehydration electrode bottles with the capacity of 80ml to reach the scale of 80 ml; after a dehydration electrode assembly is inserted into a dehydration electrode bottle, the dehydration electrode assembly is placed in a DPY-ZET type desk type electric desalting evaluation instrument to be subjected to electric dehydration treatment for 60min under the conditions of 55 ℃ and 100% power; taking the dehydration electrode assembly out of the glass dehydration electrode bottle, extracting 40ml of oil sample from the upper part of the electrode bottle by using a 10ml plastic graduated pipette, and transferring the oil sample into a Schott bottle with the capacity of 250 ml; the 250ml Schott bottle was inverted 10 times from top to bottom to mix the oil sample uniformly and then the sample was taken to test the water content and salt content as shown in Table 9. The water content and the salt content of low water-containing oil which are respectively 0.91 percent and 88.4mg/L and the water content of polymer flooding W/O type crude oil emulsion which is separated from certain salt-surfactant-polymer flooding well output liquid of the Daqing oilfield apricot five blocks are subjected to standing and sedimentation for 36h at 60 ℃ and the W/O type crude oil emulsion which is separated from the polymer flooding well output liquid of the Daqing oilfield apricot five blocks is prepared by the following steps: 5 mixing the obtained mixed oil sample, adding 100mg/L demulsifier, dehydrating with 60min 55 deg.C alternating current electrostatic field (electric field strength at 60 min: 5108V/cm), to obtain a mixture with residual water content of 0.13% and salt content of 20.2mg/L, respectively.
TABLE 9
The medicines of the components in the above examples are all commercial products.
According to the method, the crude oil containing the surfactant for oil displacement after thermochemical settling or electrochemical dehydration is doped into the W/O type crude oil emulsion with low water content produced by water flooding or polymer flooding, and deep dehydration and desalination of the crude oil containing the surfactant for oil displacement are realized through thermochemical settling or electrostatic coalescence. The content of emulsified water in each kg of crude oil containing the surfactant for oil displacement is 8.7-46 mL; the content of the surfactant for oil displacement of emulsified water in each liter of crude oil containing the surfactant for oil displacement is 151-522 mg; the water content of the W/O type crude oil emulsion produced by each kg of water flooding or polymer flooding is 58 mL-279 mL; the oil content of the surfactant crude oil containing oil displacement, which is mixed into each liter of W/O type crude oil emulsion produced by water flooding or polymer flooding, is 200 mL-1000 mL; the dosage of the block polyether type nonionic macromolecular surfactant in the W/O type crude oil emulsion which is produced by water flooding or polymer flooding and is doped with crude oil containing a surfactant for oil displacement per liter is 50 mg-150 mg; the block polyether type nonionic polymer surfactant is polyoxypropylene polyoxyethylene phenolic resin ether (AR-36).
In field application, the process flow of dehydration and desalination of crude oil containing surfactant for oil displacement used is shown in figure 1, which shows a position schematic diagram of adding crude oil containing surfactant for oil displacement into W/O type crude oil emulsion produced by water flooding or polymer flooding and adding block polyether type nonionic macromolecular surfactant into W/O type crude oil emulsion produced by water flooding or polymer flooding which is added with crude oil containing surfactant for oil displacement, the figure comprises a dehydration heating device 4, the dehydration heating device 4 is a dehydration heating furnace or a heat exchanger, the dehydration heating device 4 is connected with a dehydration device 5 through a crude oil conveying pipeline, the dehydration device 5 is an electric dehydrator or a dehydration tank, the dehydration heating device 4 is respectively connected with a crude oil 1 liquid pipeline containing surfactant for oil displacement and a W/O type crude oil emulsion 2 liquid pipeline produced by water flooding or polymer flooding through liquid inlet pipelines, a demulsifier dosing device 3 is connected on a pipeline between a confluence point of a crude oil 1 incoming pipeline containing a surfactant for oil displacement and a W/O type crude oil emulsion 2 incoming pipeline extracted by water flooding or polymer flooding and a dehydration heating device 4, and the demulsifier dosing device 3 comprises a dosing tank and a dosing pump; crude oil 1 containing a surfactant for oil displacement and W/O type crude oil emulsion 2 produced by water displacement or polymer flooding are mixed in a pipeline, a demulsifier is added, and the mixture enters a dehydration heating device 4 for heating and then enters a dehydration device 5 for dehydration. After entering an electric dehydrator or a dehydration tank for dehydration, the dehydrated crude oil 6 is conveyed to an oil depot through pipeline connection; the drainage 7 of the dehydration device is connected and conveyed to a production water treatment station through a pipeline; the dehydration device 5 is connected with the purified crude oil buffer device and the sewage sedimentation/buffer device through pipelines. The best dosing point of the block polyether type nonionic surfactant is between a junction point of a crude oil 1 incoming liquid pipeline containing the surfactant for oil displacement and a W/O type crude oil emulsion 2 incoming liquid pipeline extracted by water displacement or polymer flooding and a dehydration heating device 4, and the block polyether type nonionic surfactant has the advantages that pre-aggregation and pre-coalescence of water drops in the W/O type crude oil emulsion can be realized by utilizing a flow field and residence time in the dehydration heating device 4, and the crude oil dehydration and desalination efficiency in an electric dehydrator/dehydration tank is improved.
The surfactant-polymer flooding can be regarded as specific examples of alkali-surfactant-polymer flooding and salt-surfactant-polymer flooding at an alkali addition of 0mg/L and a salt addition of 0mg/L, respectively. The embodiments described above are intended to facilitate one of ordinary skill in the art in understanding and using the present invention. Therefore, the present invention is not limited to the embodiments described herein, and those skilled in the art should make improvements and modifications within the scope of the present invention based on the disclosure of the present invention.
Claims (7)
1. A deep dehydration and desalination method for a mine field containing oil displacement surfactant crude oil is characterized by comprising the following steps:
s1, mixing the crude oil containing the surfactant for oil displacement after thermochemical settling or electrochemical dehydration into the W/O type crude oil emulsion with low water content produced by water flooding or polymer flooding; the crude oil containing the surfactant for oil displacement is low-water-content crude oil obtained by performing thermochemical settling or electrochemical dehydration on produced liquid of alkali-surfactant-polymer flooding, salt-surfactant-polymer flooding and surfactant-polymer flooding chemical flooding;
s2, adding a demulsifier into the low-water-content W/O type crude oil emulsion which is subjected to thermal chemical sedimentation or electrochemical dehydration and contains the surfactant for oil displacement and is produced by water displacement or polymer displacement in S1 to form a blend liquid added with the demulsifier;
and S3, performing thermochemical settling or electrostatic coalescence on the blend liquid added with the demulsifier in the S2 to realize deep dehydration and desalination of the crude oil containing the surfactant for oil displacement.
2. The method for deep dehydration and desalination of the crude oil field containing the surfactant for oil displacement according to claim 1, which is characterized in that: the demulsifier is a block polyether type nonionic macromolecular surfactant.
3. The method for deep dehydration and desalination of the crude oil field containing the surfactant for oil displacement according to claim 2, which is characterized in that: the block polyether type nonionic high molecular surfactant is polyoxypropylene polyoxyethylene phenolic resin ether.
4. The method for deep dehydration and desalination of the crude oil field containing the surfactant for oil displacement according to claim 1, which is characterized in that: the content of emulsified water in each kg of crude oil containing the surfactant for oil displacement is 8.7-46 mL; the content of the surfactant for oil displacement of emulsified water in each liter of crude oil containing the surfactant for oil displacement is 151 mg-522 mg.
5. The method for deep dehydration and desalination of the crude oil field containing the surfactant for oil displacement according to claim 1, which is characterized in that: the water content of the W/O type crude oil emulsion produced by each kg of water flooding or polymer flooding is 58 mL-279 mL; the crude oil containing the surfactant for oil displacement, which is mixed in each liter of W/O type crude oil emulsion produced by water flooding or polymer flooding, accounts for 200-1000 mL.
6. The method for deep dehydration and desalination of the crude oil field containing the surfactant for oil displacement according to claim 3, which is characterized in that: the dosage of the block polyether type nonionic high molecular surfactant in the W/O type crude oil emulsion produced by water flooding or polymer flooding, which is doped with crude oil containing a surfactant for oil displacement, per liter is 50-150 mg.
7. The method for deep dehydration and desalination of the crude oil field containing the surfactant for oil displacement according to claim 1, which is characterized in that: the S3 deep dehydration and desalination of crude oil containing surfactant for oil displacement uses dehydration heating furnace, heat exchanger, electric dehydrator or dehydration tank.
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